Well head closure assembly



1 8, 1969 P. s. SIZER WELL HEAD CLOSURE ASSEMBLY Sheet Filed Oct. 10,1967 R m m w 6 N w R m g WI O" .l a g N S W 0 F 0 l A 0 a S 5 5 l D. Pl:1 y Y B n a J v 0 c 5 5 75 3 6 7 W 5 V a a ww F ooo 1 1 v 1 6 Wur w a 7W C 2 m 5 "a 4 mm 5 H p y 3, 1.969v P. s. SIZER I WELL HEAD CLOSUREASSEMBLY Filed Oct. 10, 1967 INVENTOR II-u M Phillip s Sizer BY B WWJuly 8, 1969 P. s. SIZER 3,454,084

WELL HEAD CLOSURE ASSEMBLY Filed Oct. 10, 1967 Sheet 3 of 4 -l l ?l Ill!F Z 233 p W227 2 9 A w f a 2I9\" 56 226 23 F2 '2 30 f Fl w "#k -3o4 a299 l 305 if X a 220 i /7 225 Q I TA 20 E INVENTOR 22/ Phillip S. Sizer34 p gyfllw ay'm July 8,1969 v P. SSIZER 3,454,084

WELL HEAD CLOSURE ASSEMBLY Filed Oct. 10, 1967 Sheet 4 of 4 INVENTORPhillip s. Sizer 1 MW BYWWXM'M Fig.4

United States Patent 3,454,084 WELL HEAD CLOSURE ASSEMBLY Phillip S.Sizer, Dallas, Tex., assignor to Otis Engineering Corporation, Dallas,Tex., a corporation of Delaware Filed Oct. 10, 1967, Ser. No. 674,285Int. Cl. E21b 33/035, 43/01; E21c 19/00 US. Cl. 166.6 Claims ABSTRACT OFTHE DISCLOSURE A well head closure assembly for remote or under waterwells arranged to provide vertical access into the tubing strings in thewell and having lateral flow wings through which fluids may flow fromthe well or be pumped into the well to install, remove or actuatevarious well tools in the well and to carry out various serviceoperations on the well; and flow controlling valve means disposed in thewell head closure assembly having passages directing flow of fluids intoand out of the tubing string and lateral flow passages of the well headclosure assembly and operable under remote control to close off all flowthrough the conductor. One form of the closure assembly carries thelateral flow wings, and in another form a removable sleeve is insertedin a well head having the lateral flow wings thereon, and oriented intoposition to communicate the tubing strings with the lateral flow wlngs.

This invention relates to well tools, and more particularly to well headequipment especially adapted for use at remote or underwater locations.

An important object of the invention is to provide a well head closureapparatus lowerable into and seatable in a well head at the bottom of abody of water for supporting a plurality of strings of flow conductorpipe or tubing in the well, and having means providing lateral flowpassageways communicating with lateral flow lines connected with thewell head.

A further object of the invention is to provide a well head apparatus ofthe character described wherein the support means provides for directvertical access into the well casing and tubing through the well head,and may be used to support the tubing flow strings in the well casing inflow communication with the lateral flow lines of the well.

Still another object of the invention is to provide in a well headapparatus of the character described a closure apparatus for closing thewell vertically at the upper end, and which is removable from the wellto permit re-entry thereinto in order to service or perform otheroperations on the well.

A particular object of the invention is to provide in tus includes aclosure head having flow control valvesv removably disposed therein andremovable vertically therefrom through suitable apparatus attached tothe well head; said well head apparatus having orienting means foraligning the lateral flow passageways from the cflow conduits of thewell to the lateral flow lines of the well in predetermined manner, topermit removal and reinstallation of the well tubing strings, ifdesired, without disturbing the lateral flow lines.

3,454,084 Patented July 8, 1969 Still another object of the invention isto provide a well head apparatus of the character described which hasmeans controlled from a remote position to anchor the same in place andto release the same from anchored position when desired.

A further particular object of the invention is to provide, in a wellhead closure apparatus of the character set forth, flow controlapparatus removable vertically from the closure apparatus and providedwith flow passages communicating with the lateral flow wings of theclosure apparatus or well head, said flow control apparatus having meansfor remote control of the actuation thereof. Another object is toprovide in such a flow control apparatus and well head closure assembly,means for orienting the 'well head closure assembly of the characterdescribed and having means for installing, locating, locking andremoving the same in the vertical passage of said well head closureapparatus, and means for equalizing pressures across the device topermit removal thereof through the vertical passage.

Another object of the invention is to provide, in a well head closureassembly of the character described, means protecting the verticalpassageways of the well head closure member and the flow control deviceslocated therein against deterioration by entry of fluid, mud, or otherforeign matter.

A further object of the invention is to provide a well head apparatus ofthe character described, which provides for removably supporting thetubing strings in the well head in sealing engagement therewith, andwherein means is provided for retaining the upper ends of the tubingstrings in place of the tubing string in the well heads, one of whichmeans may be the closure apparatus or flow controlling valves removablyinstalled in the vertical passages of the well head apparatus.

Additional objects and advantages of the invention will be readilyapparent from the reading of the following description of a deviceconstructed in accordance with the invention, and reference to theaccompanying drawings thereof, wherein:

FIGURE 1 is a view, partly in elevation and partly in section, showing aschematic well installation having a plurality of flow conductorsdisposed in the well supported from a permanent well head structure atthe bottom of the body of water, and showing the removable well headapparatus and flow control devices of the invention assembled therewith;

FIGURE 2 is an enlarged view, partly in elevation and partly in section,taken on the line 22 of FIGURE 5, of the upper portion of the well ofFIGURE 1, showing the well head apparatus of the invention having a flowcontrol device disposed therein;

FIGURE 2A is an enlarged view of the latching mechanism for holding thewell head apparatus connected to the permanent well head structure;

FIGURE 2B is an enlarged fragmentary sectional view showing a modifiedform of tubing support in the well head apparatus;

FIGURE 3 is an enlarged view, partly in elevation and partly in section,taken on the line 3-3 of FIGURE 6, showing a modified form of the wellhead apparatus for use with more than two flow conductors, and showing aremovable sleeve for supporting the tubing strings engaged within apermanently installed lateral flow wing head forming a part of thepermanent well head structure;

FIGURE 3A is an enlarged view, partly in elevation and partly insection, showing a modified form of support for the tubing strings foruse in the removable sleeve of the well head apparatus of FIGURE 3;

FIGURE 4 is a view, similar to FIGURE 3, showing means for connecting avertical conductor to the well head for raising and lowering the same orfor lowering well tools into and out of the bores of the apparatus ofFIGURE 3;

FIGURE 5 is a top plan view, with portions broken away, showing thesingle lateral flow wing of FIGURE 2 in which two tubing strings aresupported in the well; and,

FIGURE 6 is a top plan view, partly in section, showing the well headapparatus of FIGURE 3, having two lateral flow wings providingcommunication with four tubing strings disposed in the well bore.

In the drawings, FIGURE 1, a typical well head installation isillustrated schematically, in which a surface casing 10 having a wellcasing head 11 at its upper end sup ports by means of a sleeve 12, asurface string of casing 13 having at its upper end an outer casinghanger 14 provided with locking recesses or grooves 15 and a sealingsurface 16 therein (FIGURE 2) for supporting the usual productionstrings of casing 17 and 18. While only a single production string ofcasing 13 is shown schematically in FIGURE 1, it is obvious that morethan one string may be supported in the head 14, as shown in FIGURE 2,if desired.

The casing string 17 is suspended from a casing hanger 19, and theproduction casing string 18 is suspended from a casing hanger 20, asshown in FIGURE 2. The casing hanger 19 is locked in place in the outerhanger 14 by locking means 21 engaged in the lower recess 15 in theouter hanger, while the inner production casing string 18 carried by thehanger is locked in the outer hanger by locking means 22 engaged in theupper recess 15 in said outer casing hanger. The structure justdescribed comprises a common type of well head installation.

The bore of the casing hanger 14, above the upper production stringhanger 20, is provided with an internal annular locking recess 25 and asealing surface 26. One form of the well head closure apparatus H of theinvention is telescoped into the upper end of the bore of the casinghanger 14 and locked in place therein by locking dogs 27 which areengaged in the locking recess 25 in the bore of the hanger. The lowerend of the closure apparatus H is beveled and seats on the upper end ofthe inner production casing hanger 20.

The closure apparatus H includes a body member 30 which is provided witha pair of laterally spaced parallel longitudinal flow conduits orpassages 31 and 32 which extend throughout the length of the closuremember and are provided at their lower ends with threads (FIGURE 2A) forreceiving the threaded upper ends of tubing strings 33 and 34,respectively, whereby the tubing strings are suspended from the wellhead closure apparatus.

Suitable landing nipples 35 for well tools are disposed in each of thetubing strings below the well head closure body member, and other flowcontrol devices, such as laterally opening slidable sleeve valveassemblies 36, may be disposed in each of the flow strings to establishcirculation between the casing annulus and the bore of the particulartubing string in which each of them is mounted. At the lower end of thestring 33 is mounted a landing nipple 37 in which a flow control device38 is disposed. A cross-over coupling member or packer 39 connects thelower ends of the tubing strings 33 and 34 and is provided with alateral port 40 to effect flow communication between the two tubingstrings at that point. Suitable packing or sealing means 41 is disposedon the exterior of the cross-over packer 39 for sealing with the casingat that point.

Below the packer or cross-over member 39, the tubing strings are eachprovided with a landing nipple 42 in which suitable valves forcontrolling fiow through the tubing strings may be installed. A valve43, which may be a back flow check valve, is shown disposed in thelanding nipple 42 connected to the tubing string 34. Perforated nipples44 are provided below the landing nipples 42 at the lower end of each ofthe tubing strings for communicating with the producing formationthrough perforations 45 at the lower end of the production casingstring.

The exterior of the casing head 11 is provided with an external annularflange connecting means 11a by means of which the usual blow-outpreventers (not shown) and other well control apparatus may be connectedto the upper end of the casing head to permit landing the severalstrings of casing in the well bore, and to permit lowering the well headclosure apparatus H into place.

The present invention is concerned with the well head closure assembly Hfor closing the top of the well, sup porting the tubing string therein,and providing for control of flow of fluids from the tubing strings tolateral flow lines connected with such well head closure assembly. Thewell head closure body member 30 has lateral flow lines or conduits 51and 52 provided therein communicating with the vertical passages 31 and32, respectively, of the body member and with the bore of the tubingstrings therebelow. The vertical passages 31 and 32 of the closuremember provide for vertical entry and removal of the flow controldevices or valves 55 and 56, and for permitting other well apparatus tobe inserted into and removed from the tubing strings 33 and 34 in thewell, and to provide access to the well bore therebelow when desired.The lateral flow wing 50 of the well head closure assembly is formedwith the two arcuate flow passages 51 and 52 which communicate with thevertical passages 31 and 32, respectively. The flow wing and the flowpassages therein are connected by means of a coupling C with the lateralflow lines F1 and F2 from the well head to a remote point or to aplatform or other support means above the surface of the body of waterin which the well is located. The arcuate passages connected to the flowlines F1 and F2 provide for circulation of fluid from the flow line F1through the passage 51 of the body into the vertical passage 31 andthence into the tubing string 33 therebelow, from whence it may crossthrough the passage 40 in the cross-over device 39 into the tubingstring 34, and then flow back out of the well through the tubing string34, through the lateral flow passage 52, and thence to the flow line F2,or vice versa. It will therefore be apparent that various well apparatusmay be circulated into and out of the tubing strings by fluid pump-downoperation in the manner set forth in the patent to Schramm et 21.,3,040,808, issued June 26, 1962. The reverse flow of fluids may beaccomplished, if desired. The sliding valves 36 may be actuated by thepump-down equipment, or various types of flow controls, such as thedevices 38 and 43, may be circulated into and out of the well by suchpump-down equipment.

The body member 30 of the well head closure assembly is provided at itslower end with a plurality of lateral apertures 60, in each of which oneof the locking dogs or lugs 27 is disposed for lateral expansion andcontraction. An annular expander member 61 is slidable in an annularrecess formed in the body and is beveled at its lower end and adapted toengage between the lugs 27 and the body to hold the lugs in the expandedposition as shown in FIGURE 2A. The expander member is biased downwardlytoward the locking position, shown in FIGURE 2A, by a spring 62 disposedbetween the enlarged upper piston head 63 of the expander member and theshoulder 64 formed at the upper end of the enlarged annular pressurerecess or cylinder 65 provided in the body member for receiving theenlarged piston head of the expander member.

For moving the expander member 61 upwardly from looking engagement withthe dogs 27, fluid pressure from a remote point, such as at the surfaceof the ground or work platform, is introduced through a fluid pressureconduit line or passage 66 formed in the lateral flow wing 50 andcommunicating at its lower end with the lower portion of the annularcylinder 65 below the piston head 63 of the expander member. The fluidpressure is confined between a lower O-ring 67 and an upper O-ring 67'disposed in suitable annular recesses in the outer wall of the cylinderand engaging the outer periphery of the cylinder head and of the reducedlower portion of the expander member. The fluid pressure thus actsagainst the under side of the piston head to move the piston head andthe expander member 61 upwardly against the force of the spring 62 towithdraw the lower portion of the expander member from engagement withthe dogs'to permit the dogs to move inwardly to retracted position. Avent line 68 is formed in the flow wing and the body 30 of the headclosure communicating at its lower end with the upper portion of thecylinder 65 and also leading through the flow wing 50 to a remote pointat the well surface, whereby, if desired, fluid pressure may beintroduced into the upper portion of the cylinder to act on the piston.In such event a seal (not shown) would be disposed in the inner wall ofthe cylinder opposite the upper seal 68. Also, the conduit 68 providesfor venting fluid pressure in the upper portion of the cylinder as thepiston head and plunger are moved upward therein to permit the same tobe moved without resistance of pressure applied thereagainst.

The operating fluid pressure lines 66 and 68 communicate with similarlines or conduits formed in the flow lines F1 or F2, or with smallseparate conduits or lines connected at their ends to the couplingmember C and communicating with the conduits 66 and 68.

When the closure head assembly H is disposed in the upper end of thecasing hanger 14, it will be seen that the tubing strings 33 and 34 aresupported thereby within the production casing 18 in the usual manner.

Each of the flow control valves 55 and 56 disposed in the passages 31and 32 in the control head assembly includes an upper locking assembly70 having a laterally expansible dog 71 disposed in a cage 72 andadapted to be expanded by an expander member 73 movably downwardly by aconnector head 74 formed at the upper end of the expander sleeve, sothat the expander member is movable between the dogs and outer surfaceof the upper end of the mandrel. Such a locking device is illustrated inthe patent to Tamplen, No. 3,208,531, issued Sept. 28, 1965. The mandrel75 of the flow control device is provided with an axial blind bore 76which extends downwardly to a point below the locking assembly and has asliding sleeve valve 77 disposed therein for closing lateral ports 78and 79 communicating with the bore. The port 78 communicates with theexterior of the mandrel while the port 79 communicates at its oppositeend with an elongate arcuate fiow passage 81 which extends upwardly fromthe longitudinal bore 84 in a diverter head section 80 at the upper endof a valve assembly 85 connected to the lower end of the mandrel. Thepassageway 81 is arcuate and communicates at its upper end with thelateral arcuate flow pressure 52 in the flow wing 50. The valve assembly55 is substantially identical in construction to the valve assembly 56just described and closes the upper portion of the bore 31 of the head.The lateral flow passage 81a in the diverter head 80a of the valve 85acommunicates with the passage 51 of the flow wing 50 to divert the fluidstring 33 to the flow passage 51. The valve assembly 85 in the flowcontrol device 56 is shown to be a ball type valve which is normallyheld in the open position by fluid pressure acting downwardly on apiston 89 in the valve to cause the valve operator mechanism to move thevalve to the closed position. A valve of the type just mentioned isillustrated and de- 6 scribed in the co-pending application of WilliamW. Dollison, Ser. No. 510,189, filed Nov. 29, 1965.

For orienting the mandrel of the flow control device to position thearcuate flow diverter passage 81 in alignment with the lateral passage52 and the flow wing 50, an arcuate camming surface 91 is formed on thelower portion of the mandrel and is adapted to engage a guide lug 92disposed in the lower portion of the bore 32 of the closure head andengaging the camming surface to turn the flow control valve about itslongitudinal axis to correctly orient the diverter passage 81 withrespect to the flow passage 52. An O-ring 95 is disposed on the mandrelabove the upper end of the diverter passage 81 and engages the wall ofthe bore 32 to seal off above the lateral flow passage and the open endof the diverter passage, while a similar O-ring 96 is disposed in arecess on the exterior of the flow control device mandrel below thelateral outlet of the diverter passage 81 and seals between the borewall of the passage or bore 32 and the mandrel below the lateral outlet81 and the inlet to the lateral passage 52. Thus, fluid pressure isdirected from the passage of the valve assembly 85 into the lateral flowpassage 52 in the flow wing and thence to the flow line F2.

A lower seal member 97 is disposed in an annular groove formed on theexterior of the mandrel of the valve assembly spaced below the ring 96and provides for introduction of operating control fluid from a flowcontrol fluid line 99, which is formed in the well head body andcommunicates at its lower end with the bore of the passage 32 betweenthe seal rings 96 and 97 whereby operating fluid may be directed intothe valve assembly to move the valve assembly to open position. The flowline 99 extends along the lateral flow wing to the coupling C and mayalso be formed in the lateral flow wing F2 or the flow line F1, or maybe a separate line connected to the coupling C and extending to thesurface or other remote point for operation of the device.

The sleeve valve 78 has seal members at its upper and lower endsengaging the wall of the bore 76 on opposite sides of the lateral ports78 and 79 to close off entry of fluid through those ports into the openaxial bore 76 at the upper end of the mandrel. When the valve 78 is inthe position shown in FIGURE 2, obviously flow cannot take place throughthe lateral ports and all flow is directed from the tubing string 34through the bore '84 of the valve assembly 85 and thence through thediverter passage 81 into the lateral flow passage 52 in the flow wing50, and thence to the flow line F2. Similarly, the valve 55 in verticalbore or passage 31 directs flow from the tubing string 33 through adiverter passage 81a into the lateral flow passage 51 and the flow lineF2 connected therewith by the coupling C.

The valve assembly and its locking mandrel with its diverter passageformed therein may be run into the well by'wire line or flexible linelowering tools (not shown), in the same manner as the well toolsillustrated in the patent to Tamplen, mentioned hereinabove. Theorientingf cam surface 91 engaging the orienting lug 92 will correctlydispose the upper end of the arcuate diverter passage 81 in alignmentwith the arcuate flow passage 52 and the lateral flow wing passage 51.Thus, it will be seen that the well flow is directed from the tubingstrings to the lateral flow lines F1 and F2 by means of the diverterheads and 80a having the diverter passages 81 and 81a formed therein,while flow upwardly out of the bores 31 and 32 of the closure headassembly is prevented by the sleeve valve closing the upper passage orbore 76 of each of the mandrels.

Should it ever become necessary to equalize pressures on opposite sidesof the ball valve assembly 85, the sleeve valve 77 is moved downwardlyby a suitable prong or other tool engaging the upper end thereof anddriving the same downwardly below the lateral flow ports 78 and 79. Whenthis occurs, fluid pressure may be introduced from a conduit connectedwith the flow passage 32 into the arcuate diverter passage 81, orpressure in such passage may be relieved or equalized across the entireassembly to permit removal of the locking device and the valve assemblywith the diverter head section upwardly out of the bore in the well headclosure assembly.

A suitable lubricator (not shown) may be threaded into the screw threads31a and 32a at the upper ends of the passages in the closure head, andaccess provided in the usual or customary manner to the bore of thetubing through such conduits or lubricators.

Also, if desired, a lubricator or running and pulling tool R such asshown in FIGURE 4 may be connected to the upper end of the well headassembly H to provide direct access into the separate bores through acommon vertical passage. Such a lubricator device is illustrated in thepatent to Raulins, No. 3,103,591, issued Sept. 3, 1963, and includes abody 110 having a sleeve 111 slidable on its exterior and actuated byhydraulic fluid directed into the bore of the sleeve 111 throughoperating fluid lines 112 and 113. Operating fluid pressure directedinto the bore of the sleeve 111 through the line 112 moves the sleevedownwardly to the position shown in FIGURE 4, while pressure introducedthrough the operating fluid line 113 directs fluid into the bore of thesleeve above the flange 114 on the body 110 and moves the sleeveupwardly to withdraw the locking member 115 at the lower end of thesleeve from locking and holding engagement with the locking dogs or ringsections 116 carried in the apertures in the lower portion of the body110 and engaging in the annular locking recess 120 at the upper end ofthe well closure head assembly below the locking flange 119 formedthereon. The tubing 121 connected with the upper end of the body 120 isopen to provide access into both passages 31 and 32 in the closure headassembly, while a seal sleeve 122 carried in the bore of the body 110has packing means 123 on its exterior engaging in the upper enlargedbore of the closure head assembly. While the closure head assembly shownin FIG- URE 4 differs somewhat from that of FIGURE 3, the latchingcoupling member could be connected to the head assembly of FIGURE 2 inthe same manner, and seal 123a provided in the bore of the body 110seals against the exterior of the head assembly.

Normally, the bore of the passages 31 and 32 above the flow controldevices 55 and 56 are filled with grease or other corrosion inhibitingmaterials, and a closure cap 130 is telescoped over the upper end of thehead assembly, and has detent fingers 131 disposed in its interior andengaging in the recess 120 below the shoulder 119 on the exterior of theupper portion of the closure head. The closure cap is also similar tothe closure cap shown in the patent to Raulins No. 3,102,591, andcarries a seal 132 in its lower portion engaging the lower portion ofthe exterior of the upper projecting neck 133 of the head assembly toseal therebetween to prevent entry of fluid such as sea water and thelike into the passages 31 and 32.

It is also believed readily apparent that a connector or lubricator suchas is shown in FIGURE 8 of the patent to Raulins may be connected to theupper end of the closure head assembly, if desired, to provide fororiented access into a selected one of the passages 31 and 32 in theclosure head assembly. In such event, a suitable orienting device suchas is shown in the Raulins patent would be provided on the upper end ofthe projecting neck of the closure assembly.

From the foregoing, it will be seen that a closure head assembly H hasbeen illustrated and described which is lowerable into a Well casing tosupport the tubing strings or flow conductors in said casing andprovided with a lateral flow wing having lateral flow passages formedtherein communicating with the tubing strings or flow conductors in thewell for directing fluids from the well through the tubing strings andthe lateral flow wing to the flow lines leading to the surface or otherremote point.

It will readily be seen that the valve assemblies 55 and 56 serve asflow control valves and may be readily removed from the vertical boresin the well head closure member after suitable lubricators have beenconnected to the upper end of the well head whereby the valve assembliesmay be lifted from the well head and access provided through the wellhead to the tubing strings to perform various operations therein.

It will also be seen that the valve assemblies are provided with lateralflow diverting passages which are removable therewith and which areoriented into correct alignment with the lateral flow passages in thewell closure head by orienting means in the vertical passages of thewell head and on the flow control devices.

It will also be seen that the valves are openable and closeable by fluidpressure from a remote point to control flow from the well through thelateral flow wings, if desired. The valves thus would function in thesame manner as the usual flow control valve or Christmas tree valves ofthe usual well installation at the well head.

It is believed readily apparent that, as shown in FIG- URE 2B, thetubing strings 33 and 34 may be removably supported in the lower end ofthe bore of the well head closure assembly H, whereby the tubing stringsmay likewise be removed from within the well bore through the wellclosure head, if desired. The lower portion of each of the vertical orlongitudinal bores 31 and 32 of the well head are reduced at their lowerportion to provide a beveled stop shoulder and seal surface 141 in thelower portion of the bores 31 and 32. While only the bore 31 is shown inFIGURE 2B, it is obvious that the identical structure may be provided inthe bore 32. A hanger or head member 142 having an enlarged upperportion or head 143 provided with an O-ring or other suitable sealmember 144 in an annular groove in its exterior has a downwardly facingbeveled shoulder 145 formed thereon which is adapted to engage theupperly facing shoulder 140 in the lower portion of the bore 31 of theclosure head. A tubing string is threaded into the coupling portion 146at the lower end of the support head or hanger member, and when thehanger is landed in the closure head bore, as shown in FIGURE 2B, thelower end of the valve assembly 55 is adapted to engage the upper end148 of the hanger 142 to prevent upward movement thereof. The seal ring144 prevents fluid flow between the air and the bore of the head in theusual manner. With the structure just described, it is apparent that thevalve assembly 55 may be removed from the bore 31 in the manner alreadydescribed, and a string of tubing or other suitable lifting means havingscrew threads on its lower end lowered into the bore 31 of the closurehead and engaged in the upper threads 147 in the bore of the hangerwhereupon the hanger and the tubing string supported thereby may belifted from the well through the bore 31 of the closure head assembly.The diameter of the coupling portion 146 of the hanger is equal orslightly greater than the external diameter of the couplings joining theseveral sections of the tubing therebelow so the tubing string willreadily pass through the opening below the shoulder 145 in the bore ofthe closure head.

A modified form of closure head assembly HC is shown in FIGURES 3 and3A. In this form of the device, a removable cylindrical sleeve 0rcartridge C is disposed within the bore of the closure head body 220,and the vertical flow passages 231 and 232 are formed in the sleeve.

In this form of the device, the outer body 220 of the closure headassembly HC may be substituted for the outer casing hanger 14, and mayhave the outer casing string 13 connected to its threaded lower end 221by the coupling 2210!. The body is therefore substituted for the outercasing hanger 14, and the outer body 220 thus becomes a part of thecasing head assembly and functions as the outer casing or productionhanger 14.

The lower portion of the bore 225 of the body 220 is provided withinternal annular recesses therein for receiving the locking dogs 21 and22 of the casing hangers 19 and to support the casing strings 17 and 18in the manner first described. Thus, the outer body 220 of the hangerassembly HC remains fixed in place on the well head, while thecylindrical sleeve or cartridge C is removable from within the bore ofthe body 220.

Latch means 222 are provided exteriorly adjacent the upper end of thebody and lock the same in the outer hanger or in the same manner as theouter casing hanger 14' first described. Lateral flow Wings 250 and 250aare formed on the body 220 and project laterally therefrom as shown inFIGURE 6. While two flow wings are shown, it is obvious that only onemay be used, if desired. An arcuate lateral flow passage 251 is formedin the wing 250 and a similar arcuate lateral flow passage 25001 isformed in the flow wing 250a. It is to be understood, of course, thatthe flow passage 2510 may be formed in the wing 250 if desired, andextend laterally to the coupling C in the same manner as the flowpassages 51 and 52 of the form first described.

The cylindrical sleeve or cartridge C is removably anchored in the bore225 of the body 220 by locking dogs or lugs 226 and a locking sleeve 227at the upper end of the cartridge. Such a locking mechanism is shown inthe patent to Raulins, 3,090,438, issued May 21, 1963. The dogs 226prevent upward movement of the sleeve within the bore of the body 220while the lower beveled end 228 of the sleeve engages a shoulder at theupper end of the production casing hanger 20, which is locked in placein the lower portion of the bore 225 of the closure head outer body, andis held thereby against downward movement in the outer body.

The inner cylindrical sleeve cartridge C includes the body 230 havingbores 231 and 232 formed therein for receiving the flow control devicesor valve assemblies 55 and 56 in the same manner as the form firstdescribed. The tubing strings 33 and 34 are connected by screw threads(not shown), in the lower portions of the bores 231 and 232 in the samemanner as the form first described. Also, if desired, the lower portionof each of the bores 231" and 232 may be provided with an internalannular beveled seat 240 and an enlarged seal bore 241 thereabove forreceiving and supporting a hanger head or coupling 242 to which theupper end of the tubing string 33 is threaded, as shown in FIGURE 3A.The hanger member or head 242 has an external annular recess and a sealring 244 is disposed in the recess and seals v between the coupling andthe bore wall 241. The lower portion of the head or hanger member isprovided with a beveled shoulder 245 which engages the upwardly facingshoulder 240 to support the tubing string. The lower portion of the bore241a below the shoulder is sufliciently large to pass the couplings andother protuberances on the string 33 below the hanger. The length of thehanger 243 is such that its upper end 248 is disposed to be engaged bythe lower end of the flow controlling valve assembly 55, as shown inFIGURE 3A, whereby the hanger is securely held in place in the bore 241and cannot be displaced upwardly therefrom, being locked in place by thelocking mechanism of the valve assembly.

The body of the inner sleeve or cartridge C is provided with lateralopenings or apertures 270 and 271 which are arranged to be disposed inalignment and in flow communication with the lateral passages 251 and251a in the flow wing 250 and the flow wing 250a. Also, the lateralopenings 270 and 271 are arranged to communicate and be disposed inalignment with the arcuate flow diverting passages 81 and 81a in thevalve assemblies 55 and 56, so that fluid flowing from the tubingstrings 33- and 34 will go through the valve assemblies and through thearcuate flow diverter head passages 81 and 81a, then through theopenings 270 and 271 into the lateral flow passages 251 and 251a in theflow wings.

A seal ring 301 is disposed in a suitable recess on the exterior of theinner sleeve 230 above the uppermost lateral flow opening 271, a secondseal ring 30-2 is disposed in a suitable recess in the exterior of thesleeve between the uppermost lateral opening 271 and the next higherlateral opening 270, and a similar seal ring 303 is disposed in asuitable recess in the exterior of the body 230 below the lateralopening 270. The seal rings 301, 302, and 303 seal between the innerbody 230 of the cartridge C and the bore of the outer closure head body220, whereby fluids flowing through the lateral openings 270 and 271 inthe cartridge are directed into the appropriate lateral flow passages251 and 251a.

Additional lateral arcuate flow passages may be provided in the flowwings 250 and 250a, and apertures communicating therewith sealed in thesame manner to provide "four passages, as shown in FIGURE 6. In suchcase, the passages would be spaced longitudinally in order that sealrings such as the seal rings 301, 302, and 303 may be disposedtherebetween to direct fluids into such lateral flow passages.

The lateral apertures 270 and 271 of the cartridge are oriented intoalignment with the lateral flow passages 251 and 251a by means of acamming surface 310' formed on the lower exterior portion of thecartridge body 230 and engaging an orienting leg 311, shown in dottedlines in FIGURE 3, whereby the inner sleeve or cartridge C is turnedabout its longitudinal axis to the correct position to dispose thelateral apertures 270 and 271 in alignment and flow'communication withthe lateral arcuate passages 251 and 251a in the flow wings.

Threads 231a and 2320 are formed in the upper portions of the bores 231and 232 in the inner sleeve and provide means for coupling lubricatorsor the like to the sleeve in fiow communication with the bores in thesleeve in the same manner as with the passages of the form firstdescribed.

An internal annular groove 229 is formed in the upper portion of thelocking sleeve 227 on the body 230 for engaging by suitable running andretrieving tools whereby the locking sleeve 227 may be actuated to lockand release the dogs 226 to effect insertion and removal of thecartridge C in the outer body 230 of the closure head assembly.

The neck 233 at the upper end of the outer body is provided with anexternal annular flange 219, similar to the flange 119 of the head firstdescribed, by means of which blowout preventers and similar devices maybe connected to the upper end of the outer body 230. Also, the flangeand the annular groove 219a formed therebelow functions in the samefashion as the groove 120 to receive the locking dogs or detent fingersof the lubricator devices R, or cap in the manner already described inconnection with the form first described.

Longitudinally spaced annular grooves 320 and 321 are formed in theexterior of the sleeve 220 andseal rings 304 and 305 disposed insuitable grooves on the exterior of the body 230 seal between the bodyand the closure member 220, so that operating fluid from the lines 299and 298 may be directed into the flow controlling valve assemblies tooperate the valves in the manner already described.

The valve assemblies disposed in the longitudinal bores 230 and 231 areidentical to those first described and function in the same manner,being removable through lubricator from the vertical bores 231 and 232in the manner already described.

It will now be seen that this modified form of the device provides for apermanent lateral flow wing installation including an outer body and aremovable inner sleeve or cartridge, carrying the tubing stringstherewith disposed in the outer body and insertable and removabletherefrom without disturbing the lateral flow installation. Also, itwill be seen that this form of the device provides for separate removalof the tubing strings, if desired, by use of the tubing hanger member242 for supporting the tubing strings 33 and 34.

The inner sleeve or cartridge is properly oriented Wit respect to thelateral flow passages by the orienting cam surface 310 and the lug 311,while the valves are oriented in their relationship to the passages bythe cam surfaces 91 on the valves and the lugs 92 in the bores 230 and231, so that a continuous flow passage is provided from the tubingstrings through the arcuate diverter passages in the valve assemblies tothe lateral flow lines F1 and F2. It is also believed readily apparentthat the valve assemblies may be removed from the cartridge for accessto the tubing, and, if desired, the tubing strings themselves may beeach individually removed, or both removed, leaving the sleeve orcartridge in place, or that the cartridge may be removed lifting thetubing strings therewith. If desired, the valves may be left in place inthe longitudinal bores in the inner sleeve or cartridge while liftingthe cartridge and the tubing strings supported therewith.

The foregoing description of the invention is explanatory only, andchanges in the details of the construction illustrated may be made bythose skilled in the art, within the scope of the appended claims,without departing from the spirit of the invention.

What is claimed and desired to be secured by Letters Patent is:

1. A well head closure assembly for use on a well having a casingtherein, including: a body member adapted to be connected in closedrelationship to the casing; longitudinal flow passage means in said bodymember communicating with the casing in the Well; means for supporting awell tubing string in said body member in flow communication with theflow passage means; a lateral flow conductor means on said body memberhaving means for connection to a lateral flow line; and flow controlmeans releasably disposed in said longitudinal passage means of saidbody member and having means providing a flow directing passage from thebore of the tubing string supported in the body member to the lateralflow conductor means of the body member.

2. A device of the character set forth in claim 1 wherein said flowcontrol means includes: a valve having means operable from a remotepoint for controlling flow through said flow directing passage of saidcontrol means from the tubing to the lateral flow conductor means of thebody member.

3. A well head closure assembly of the character set forth in claim 1wherein said body member includes an outer tubular member having lateralflow passage means formed thereon communicating with the bore of saidtubular member; and an inner body member releasably disposed in saidouter member in sealed relationship therewith, said inner member havingsaid longitudinal flow passage means formed therein and lateral flowpassage means communicating with said lateral flow passage means in saidouter tubular member; and means for releasing and locking the innermember in said outer tubular member.

4. A well head closure assembly for use on a well having a casingtherein including: a body having means for connecting the same to a wellcasing; said body having a plurality of longitudinal bores therein; saidbody having means at one end of each of said longitudinal bores forreceiving and connecting a well flow conductor thereto with such wellflow conductor opening into said bore when said flow conductor isconnected to said body; each of said bores being provided with internallatch groove means engageable by locking means of well flow controldevices for releasably securing well flow control devices in said bores;said body having separate flow conductor passages therein communicatingwith the longitudinal bores therein and disposed for coaction with saidwell fiow control devices to control flow through said bores and saidpassages; and internal annular seal surface provided in each of saidbores engageable by sealing means of said well devices whereby flow offluids through each of said bores is directed through .said well flowcontrol devices to the separate flow passage communicating therewith;said body being provided with second latch groove means engageable byrunning and retrieving tools whereby the body and the flow conductorsconnected therewith may be lowered and raised by said running andretrieving tools.

5. A well head closure assembly of the character set forth in claim 4and including: a well flow control device disposed in each of saidlongitudinal bores and each communicating with one of the separate fiowpassages in said body for controlling flow from the flow conductor intothe longitudinal bore and through said flow passages of said body.

6. A Well head closure assembly of the character set forth in claim 3wherein the body includes an outer tubular member adapted to beconnected to the well casing, and an inner removable cartridge removablydisposed in the outer member and releasably locked in sealed relationship therewith, said inner removable cartridge having saidlongitudinal bores formed therein and provided with flow passagescommunicating said bores with the flow conductor passages of the outertubular member of the body.

7. A well head closure assembly of the character set forth in claim 5including hanger means for removably supporting a well flow conductor ineach of said longitudinal bores of said body inflow communicationtherewith, each said hanger means being removably locked in the bore bythe flow control device disposed therein.

8. A well head closure system comprising: an outer body member supportedOn. a well casing; an inner cartridge member releasably locked withinsaid outer body member, said inner member having flow passage meanstherein and including remotely controllable valve means for controllingfluid fiow between a tubing string operably connected with said innermember and said flow passage means; means on said inner and said outermember for releasably securing said inner member in said outer member;and lateral flow passage means on said outer member communicating withthe flow passage means of the inner member whereby operation of saidvalve means controls flow through said flow passage means from saidtubing string to said outer member.

9. A well head closure assembly of the character set forth in claim 8wherein the flow passage means of said inner member is provided withmeans engageable by locking means on said valve means for releasablysecuring said valve means in said flow passage means of said innermember.

10. A well head closure system of the character set forth in claim 9including hanger means removably supporting said tubing string in saidinner member, said hanger means being locked in said inner member bysaid valve means.

References Cited UNITED STATES PATENTS 3,064,735 11/1962 Bauer et al.166-.6 3,102,591 9/1963 Raulins 166.6 3,189,097 6/1965 Haeber 166-.63,332,493 7/1967 Jones l6675 3,347,311 10/1967 Word 166-.6 3,353,59511/1967 Nelson et al. 66-.6

DAVID H. BROWN, Primary Examiner.

US. Cl. X.R. l6672, 89

